A restriction engaging system includes, a restriction engager, one or more restrictions, and at least one counter configured to permit or prevent passage of a restriction engager through one of the one or more restrictions.

Patent
   9038656
Priority
May 07 2009
Filed
Dec 30 2011
Issued
May 26 2015
Expiry
Jan 22 2031
Extension
625 days
Assg.orig
Entity
Large
0
205
currently ok
1. A system, comprising:
one or more restriction engagers;
one or more restrictions; and
at least one counter configured to permit or prevent passage of a restriction engager through one of the one or more restrictions, the at least one counter configured to be responsively indexed each time one of the restriction engagers passes through the one of the one or more restrictions, the at least one counter preventing passage of an additional one of the restriction engagers after a selected number of the restriction engagers have passed the one of the one or more restrictions.
2. The system of claim 1, wherein the restriction engager is a ball.
3. The system of claim 1, wherein the one of the one or more restrictions include a plurality of arms that are movable between a first position that allows passage of a restrictor engager and a second position that prevent passage of a restrictor engager and the at least one counter is configured to allow movement of the plurality of arms from the first position to the second position as long as the at least one counter has indexed no more than a selected number of times but prevent movement of the plurality of arms from the first position to the second position after the at least one counter has indexed the selected number of times.
4. The system of claim 1, wherein the one or more restrictions is a plurality of restrictions and each of the plurality of restrictions has at least one counter in operable communication therewith configured to permit passage of a selected number of the restriction engagers before preventing passage of an additional one of the restriction engagers thereby.
5. The system of claim 4, wherein the selected number of restriction engagers passable by each of the plurality of restrictions is independently selectable from one another.
6. The system of claim 1, wherein fluid flow is restricted from passing by the restriction engager when the restriction engager is prevented from passing a restriction.
7. The system of claim 6, wherein the restriction to fluid flow past the restriction engager allows pressure to build thereacross.
8. The system of claim 1, wherein the one or more restrictions includes members that are allowed to move when the one or more restrictions are configured to permit passage of a restriction engager.
9. The system of claim 8, wherein the movement includes movement that is radially outwardly.
10. The system of claim 1, wherein the one or more restrictions includes members that are prevented from moving when the one or more restrictions are configured to prevent passage of a restriction engager.
11. The system of claim 1, wherein the one or more restrictions include members that are allowed to deform when the one or more restrictions are configured to permit passage of a restriction engager.
12. The system of claim 1, wherein the one or more restrictions include members that are prevented from deforming when the one or more restrictions are configured to prevent passage of a restriction engager.
13. The system of claim 1, wherein the at least one counter includes an element that moves longitudinally each time the at least one counter is indexed.
14. The system of claim 13, wherein the element is prevented from longitudinally moving after the at least one counter has indexed a selected number of times.
15. The system of claim 13, wherein the element allows at least a portion of the plurality of arms of the one of the one or more restrictions to move when the element is moved longitudinally and prevents the at least a portion of the plurality of arms from moving when the element is not moved longitudinally.
16. The system of claim 13, wherein the element advances incrementally further in a same direction each time the at least one counter is indexed.
17. The system of claim 13, wherein the element comprises a sleeve or a ram.

This application is a divisional application of U.S. patent application Ser. No. 12/437,412, filed May 7, 2009 now U.S. Pat. No. 8,261,761, the entire contents of which are incorporated herein by reference.

In industries concerned with earth formation boreholes, such as hydrocarbon recovery and gas sequestration, for example, it is not uncommon for various operations to utilize a temporary or permanent plugging device. Sometimes plugging is desirable at a first location, and subsequently at a second location. Moreover, additional plugging locations may also be desired and the plugging can be sequential for the locations or otherwise. Systems employing droppable members, such as balls, for example, are typically used for just such purpose. The ball is dropped to a ball seat positioned at the desired location within the borehole thereby creating the desired plug.

In applications where the first location is further from surface than the second location, it is common to employ seats with sequentially smaller diameters at locations further from the surface. Dropping balls having sequentially larger diameters allows the ball seat furthest from surface to be plugged first (by a ball whose diameter is complementary to that seat), followed by the ball seat second furthest from surface (by a ball whose diameter is complementary to that seat) and so on.

The foregoing system, however, creates increasingly restrictive dimensions within the borehole that can negatively impact flow therethrough as well as limit the size of tools that can be run into the borehole. Systems and methods that allow operators to plug boreholes at multiple locations without the drawbacks mentioned would be well received in the art.

Disclosed herein is a restriction engaging system. The system includes, a restriction engager, one or more restrictions, and at least one counter configured to permit or prevent passage of a restriction engager through one of the one or more restrictions.

The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:

FIG. 1 depicts a cross sectional view of a selectively movable seat arrangement disclosed herein in a resting position;

FIG. 2 depicts a cross sectional view of the selectively movable seat arrangement of FIG. 1, shown in an open position;

FIG. 3 depicts a cross sectional view of the selectively movable seat arrangement of FIG. 1, shown after having passed one restriction engager;

FIG. 4 depicts a cross sectional view of the selectively movable seat arrangement of FIG. 1, shown preventing passage of a restriction engager after having passed a selected number of the restriction engagers;

FIG. 5 depicts a partial cross sectional view of an alternate embodiment of a selectively movable seat arrangement disclosed herein shown in a restriction engager passing position;

FIG. 6 depicts a partial cross sectional view of the selectively movable seat arrangement of FIG. 5 shown in a restriction engager non-passing position; and

FIG. 7 depicts a partial cross sectional view of the tubular of FIG. 5 taken at arrows 7-7; and

FIG. 8 depicts a partial schematic view of a plurality of selectively movable seat arrangements disclosed herein positioned within a wellbore.

A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.

Embodiments of the selectively movable seat arrangement disclosed herein are positionable within a borehole tubular or open hole and maintain a seat arrangement or restriction to a member or restriction engager after having allowed a selected number of restriction engagers to pass therethrough. When the restriction is maintained, the restriction engager can sealingly engage the restriction thereby sealing the borehole tubular to flow therepast. Such a seal allows for the creation of a pressure differential in the borehole that is usable by operators for such things as actuation of tools and fracturing of formations, for example.

Referring to FIGS. 1 and 2, an embodiment of the selectively movable seat arrangement 10 disclosed herein in a resting position and an open position, respectively. The selectively movable seat arrangement also described herein as a selective landing configuration 10 includes, a member described herein as a restriction engager 14 and illustrated herein as a ball, one of one or more seat arrangements described herein as restrictions 18 and illustrated herein as a ball seat, and a counter 22. The counter 22 is configured to index each time one of the restriction engagers 14 passes through the restriction 18. The restriction 18, of this embodiment, has a plurality of pivot arms 26 that are pivotal about pivot points 28 between an impassable position also referred to herein as a first pivot arm position and a passable position also referred to herein as a second pivot arm position. Each of the pivot arms 26 has a first end 38 and a second end 42. When in the first pivot arm position (shown in FIG. 1) the first ends 38 are adjacent to one another to form a ring shaped continuous reduced dimension surface 46 with which the restriction engager 14 is engagable. It should be noted that the restriction engager 14 may sealingly engage with the reduced dimension surface 46, however, it is not required. When in the second pivot arm position (shown in FIG. 2) the first ends 38 are displaced radially outwardly defining an opening 50 sized to permit passage of the restriction engager 14 therethrough. The pivot arms 26 in one embodiment may be rotationally biased by a biasing member (not shown) such as a torsional spring, for example, that biases them toward the first pivot arm position.

Movement of the pivot arms 26 from the first pivot arm position to the second pivot arm position is accomplished by urging a restriction engager 14 therethrough with pressure, for example. Ramped surfaces 54 on the first ends 38 are configured to cause the first ends 38 to move radially outwardly in response to a restriction engager 14, such as a ball, being urged thereagainst. Movement of the pivot arms 26 to the second pivot arm position causes the second ends 42 to move radially inwardly. This radial inward movement causes a tooth 58 on each of a plurality of rams 62 to disengage teeth 66 on an outer radial surface 70 of the second ends 42 of the pivot arms 26. Once the tooth 58 of the ram 62 is disengaged the ram 62 is able to move longitudinally under a biasing load provided by a biasing member 74, disclosed herein as a compression spring.

An escapement 78, illustrated herein as a lever 82 pivotal about pivot point 84, engages with teeth 86 on an inner surface 90 of a tubular 94, such as a casing or drillstring, positioned within a wellbore 98, limits the longitudinal movement of the ram 62. The lever 82 and teeth 86 are sized and positioned to allow the ram 62 to advance only a specific dimension each time the tooth 58 disengages from the teeth 66. This dimension coincides with the spacing between the adjacent teeth 66. In so doing, the escapement 78 assures that the tooth 58 will reengage with the next tooth 66 each time the pivot arms 26 return to the first pivot arm position. The lever 82 can be rotationally biased, in a direction of arrow 100, by a biasing member (not shown) such as a torsional spring, for example, to assure that the lever 82 engages with the teeth 86.

Referring to FIG. 3, the lever 82 can also be sized such that it contacts the outer radial surface 70 when the pivot arms 26 are moved back to the first pivot arm position thereby rotating the lever 82 in a direction opposite to the direction of arrow 100, disengaging the lever 82 from the teeth 86 in the process. (Note: the radial surface 70 also exists between each of the teeth 66). By doing so the lever 82 is properly positioned to engage with the next tooth 86 as soon as the pivot arms 26 begin pivoting again toward the second pivot arm position. This sequential indexing of the tooth 58 along the teeth 86 defines the counter 22.

Referring to FIG. 4, the number of teeth 66 is selected to establish the number of restriction engagers 14 that the counter 22 will allow to pass the restriction 18. Once the lever 82 is disengaged from the last tooth 66 the lever 82 will continue to be biased against the surface 90. However, without any additional teeth 66 for the lever 82 to engage there is nothing to stop the ram 62 from moving under the urging of the biasing member 74. As such, the ram 62 will stroke until contact is made with a stop 104, shown here on the tubular 94, although other mechanical features definable of full travel of the ram 62 are contemplated.

An annular dimension of the first end 38 of the pivot arms 26 is set to essentially fill an annular gap 108 defined between the outer radial surface 70 and the inner surface 90. By filling the annular gap 108, the first end 38 prevents any additional radial outward pivoting of the pivot arms 26. This non-pivoting condition of the pivot arms 26 maintains the restriction 18 thereby preventing passage of the restriction engager 14 and providing a sealing seat for the restriction engager 14 to seal to. The foregoing structure allows an operator to selectively set how many restriction engagers 14 will pass each restriction 18 before the restriction 18 is maintained, thereby preventing additional restriction engagers 14 from passing.

Referring to FIGS. 5 and 6, an alternate embodiment of a selective landing configuration 110 is illustrated. As with the landing configuration 10 the landing configuration 110 permits a selectable number of restriction engagers 114 to pass a restriction 118 before a counter 122 maintains the restriction 118 impassable by additional restriction engagers 114. The counter 122 is configured to index each time one of the restriction engagers 114 passes through the restriction 118. The restriction 118, of this embodiment, has a plurality of deformable arms 126 that are able to elastically deform between an impassable position also referred to herein as a first deformable arm position and a passable position also referred to herein as a second deformable arm position in the fashion of a collet. Each of the deformable arms 126 has a first end 138 and a second end 142.

When in the first deformable arm position (shown in FIG. 6) the first ends 138 seal to one another to form a ring shaped continuous reduced dimension surface 146 that is sealingly engagable with the restriction engager 114. When in the second deformable arm position (shown in FIG. 5) the first ends 138 are displaced radially outwardly defining an opening 150 sized to permit passage of the restriction engager 114 therethrough. An annular recess 154 in an inner radial surface 158 of a tubular 162 within which the landing configuration 110 is positioned, receives the first ends 138 as the deformable arms 126 are deformed. A nonrecessed portion 166 of the inner radial surface 158 maintains the deformable arms 126 in a nondeformed orientation (first deformable arm position) when the first ends 138 are longitudinally aligned therewith. It is precisely this longitudinal alignment between the first ends 138 of the deformable arms 126 and the nonrecessed portion 166 that the counter 122 controls to allow or prevent the passing of the restriction engager 114.

The counter 122 includes a rotationally indexable sleeve 170 that is longitudinally movable against a biasing member 182 that longitudinally biases the sleeve 170 and the deformable arms 126 in a direction wherein the nonrecessed portion 166 radially supports the deformable arms 126. The restriction 118 and the sleeve 170 are therefore longitudinally movable in response to a restriction engager 114 contacting the deformable arms 126 and providing a longitudinal urging against them in response to pressure applied thereto. The biasing member 182 can reset the sleeve 170 and the deformable arms 126 back to the first deformable arm position after the restriction engager 114 has passed therethrough. Ramped surfaces 184 assure the deformable arms 126 return to the first deformable arm position while also preventing them from wedgably engaging within the annular recess 154.

Referring to FIG. 7, a plurality of slots 186, with three slots 186A-186C being shown, and a saw tooth stop surface 188 formed in an inner radial surface 190 of the tubular 162 define the extent of the longitudinal movement of the sleeve 170, the deformable arms 126 and the restriction 118. A plurality of tabs 194 radially proud of an outer radial surface 198 of the sleeve 170 slidably engages the slots 186. When the tabs 194 are bottomed against surface 202A or 202B from slot 186A or 186B, respectively, the longitudinal travel of the sleeve 170 allows the first ends 138 of the deformable arms 126 to move into longitudinal alignment with the annular recess 154. The deformable arms 126 being radially unsupported are able to deform from the first deformable arm position to the second deformable arm position, thereby permitting the restriction engager 114 passage by the restriction 118. However, once the sleeve 170 has rotationally indexed to the point that the tab 194 is engaged with the slot 186C, the bottom 202C prevents longitudinal movement of the sleeve 170 (and the deformable arms 126) such that the first ends 138 of the deformable arms 126 remain radially supported by the nonrecessed portion 166. The nonrecessed portion 166 thereby preventing deformation of the deformable arms 126 from the first deformable arm position to the second deformable arm position and passage of the restriction engager 114 therethrough.

Angled surfaces 206 between the slots 186 and angled surfaces 210 on an end 214 of the tabs 194 cause rotational indexing the sleeve 170 when the sleeve 170 is moved toward the bottoms 202. Similarly, the saw tooth stop surface 188 and the angled surface 218 on the tabs 194 cause the sleeve 170 to rotationally index in response to movement of the sleeve 170 under urging of the biasing member 182. Rotational stop surfaces 222 on the saw tooth stop surface 188, act as an escapement 226 to prevent rotation of the sleeve 170 beyond the next slot 186, thereby assure indexing of only one slot 186 per passage of one of the restriction engagers 114.

The foregoing structure provides a well operator with the means to set a restriction 118 to selectively pass a desired number of restriction engagers 114 by forming the tubular 162 with the desired number of shallow slots 186A and 186B before a deep slot 186C.

While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are used to distinguish one element from another. Furthermore, the use of the terms a, an, etc. do not denote a limitation of quantity, but rather denote the presence of at least one of the referenced item.

Xu, Yang, Gerrard, David P.

Patent Priority Assignee Title
Patent Priority Assignee Title
1883071,
2277816,
2376594,
2448423,
2562455,
2769454,
2812717,
2822757,
2973006,
3007527,
3013612,
3117797,
3148731,
3211232,
3263752,
3358771,
3510103,
3517939,
3566964,
3583714,
3599998,
3667505,
3669462,
3703104,
3727635,
3761008,
3797255,
3901315,
3954138, Nov 14 1973 Entreprise de Recherches et d'Activities Petrolieres Elf Safety plug for sealing-off the tubing of a producing oil or gas well
3997003, Jun 09 1975 Halliburton Company Time delay nipple locator and/or decelerator for pump down well tool string operations
4067358, Jul 18 1975 Halliburton Company Indexing automatic fill-up float valve
4160478, Apr 25 1977 Halliburton Company Well tools
4176717, Apr 03 1978 Cementing tool and method of utilizing same
4190239, Jun 17 1977 Walter, Sticht Shock absorber assembly and installation
4246968, Oct 17 1979 Halliburton Company Cementing tool with protective sleeve
4260017, Nov 13 1979 DOWELL SCHLUMBERGER INCORPORATED, Cementing collar and method of operation
4291722, Nov 05 1979 Halliburton Company Drill string safety and kill valve
4292988, Jun 06 1979 HUGHES TOOL COMPANY A CORP OF DE Soft shock pressure plug
4355685, May 22 1980 HALLIBURTON COMPANY, DUNCAN, OK A CORP OF DE Ball operated J-slot
4390065, Jun 12 1980 RICHARDSON, CHARLES Apparatus for well treating
4423777, Oct 02 1981 Baker International Corporation Fluid pressure actuated well tool
4433726, Feb 18 1982 Baker Oil Tools, Inc. Energized packer anchor seal assembly
4438811, Aug 16 1982 Halliburton Company Latch for use in a well
4448216, Mar 15 1982 Halliburton Company Subsurface safety valve
4474241, Feb 14 1983 HALLIBURTON COMPANY, A CORP OF DEL Differential fill valve assembly
4478279, Oct 12 1982 Hydril Company Retrievable inside blowout preventer valve apparatus
4513822, Jun 09 1983 Hughes Tool Company Anchor seal assembly
4537383, Oct 02 1984 Halliburton Company Valve
4554981, Aug 01 1983 Hughes Tool Company Tubing pressurized firing apparatus for a tubing conveyed perforating gun
4566541, Oct 19 1983 Compagnie Francaise des Petroles Production tubes for use in the completion of an oil well
4576234, Sep 17 1982 Schlumberger Technology Corporation Full bore sampler valve
4583593, Feb 20 1985 Halliburton Company Hydraulically activated liner setting device
4655290, Dec 16 1985 Hughes Tool Company Latching production seal assembly
4657078, Dec 30 1985 Hughes Tool Company Method and device for testing a well bore packer
4662785, Feb 18 1983 NOVACORP INTERNATIONAL CONSULTING LTD , A CORP OF CANADA Apparatus and method for connecting subsea production equipment to a floating facility
4669538, Jan 16 1986 Halliburton Company Double-grip thermal expansion screen hanger and running tool
4711326, Jun 20 1986 Hughes Tool Company Slip gripping mechanism
4714116, Sep 11 1986 Downhole safety valve operable by differential pressure
4715445, Dec 09 1986 Hughes Tool Company Latch and retrieving assembly
4726425, Dec 16 1985 Hughes Tool Company Combination landing unit and seal assembly
4729432, Apr 29 1987 HALLIBURTON COMPANY, A CORP OF DE Activation mechanism for differential fill floating equipment
4762447, Sep 23 1986 Optima Industries, Inc. Dual-plane high-speed collet
4823882, Jun 08 1988 TAM INTERNATIONAL, INC.; TAM INTERNATIONAL, A TEXAS CORP Multiple-set packer and method
4826135, Feb 12 1987 Scandot System AB Arrangement for a valve assembly for a liquid jet printer
4856591, Mar 23 1988 BAKER HUGHES INCORPORATED, 3900 ESSEX LANE, STE 800, HOUSTON, TX 77027, A CORP OF DE Method and apparatus for completing a non-vertical portion of a subterranean well bore
4893678, Jun 08 1988 Tam International Multiple-set downhole tool and method
4944379, Nov 05 1987 Dynamic Research and Development Corp. Torque limiter
4949788, Nov 08 1989 HALLIBURTON COMPANY, A CORP OF DE Well completions using casing valves
4979561, Nov 08 1989 HALLIBURTON COMPANY, A CORP OF DE Positioning tool
4991653, Nov 08 1989 Halliburton Company Wash tool
4991654, Nov 08 1989 HALLIBURTON COMPANY, A CORP OF DE Casing valve
5020946, Nov 28 1989 Simon Nann KG, Fabrik fuer Spannwerkzeuge Tool chuck coolant system
5029643, Jun 04 1990 Halliburton Company Drill pipe bridge plug
5029644, Nov 08 1989 HALLIBURTON COMPANY, DUNCAN, OK A CORP OF DE Jetting tool
5056599, Apr 24 1989 Walter B., Comeaux, III Method for treatment of wells
5117913, Sep 27 1990 DRESSER INDUSTRIES, INC , A CORP OF DE Chemical injection system for downhole treating
5207274, Aug 12 1991 Halliburton Company Apparatus and method of anchoring and releasing from a packer
5230390, Mar 06 1992 Baker Hughes Incorporated; BAKER HUGHES INCORPORATED A CORPORATION OF DE Self-contained closure mechanism for a core barrel inner tube assembly
5244044, Jun 08 1992 Halliburton Company Catcher sub
5297580, Feb 03 1993 High pressure ball and seat valve with soft seal
5305837, Jul 17 1992 Smith International, Inc. Air percussion drilling assembly for directional drilling applications
5325917, Oct 21 1991 Halliburton Company Short stroke casing valve with positioning and jetting tools therefor
5335727, Nov 04 1992 Atlantic Richfield Company Fluid loss control system for gravel pack assembly
5343946, Aug 09 1993 Hydril USA Manufacturing LLC High pressure packer for a drop-in check valve
5343954, Nov 03 1992 Halliburton Company Apparatus and method of anchoring and releasing from a packer
5381862, Aug 27 1993 Halliburton Company Coiled tubing operated full opening completion tool system
5394941, Jun 21 1993 Halliburton Company Fracture oriented completion tool system
5398947, Dec 13 1993 COOK, WARREN R Self-aligning collet
5425424, Feb 28 1994 Baker Hughes Incorporated; Baker Hughes, Inc Casing valve
5529126, Oct 03 1990 Expro North Sea Limited Valve control apparatus
5551512, Jan 23 1995 Baker Hughes Incorporated Running tool
5567093, Apr 11 1995 Seal for coolant-fed tools
5609178, Sep 28 1995 Baker Hughes Incorporated Pressure-actuated valve and method
5620050, Aug 12 1993 Weatherford Lamb, Inc Method for setting hydraulic packers that enable placement of gravel pack in a downhole oil and gas well
5695009, Oct 31 1995 Sonoma Corporation Downhole oil well tool running and pulling with hydraulic release using deformable ball valving member
5704393, Jun 02 1995 Halliburton Company Coiled tubing apparatus
5762142, Jun 02 1995 Halliburton Company Coiled tubing apparatus
5775421, Feb 13 1996 Halliburton Company Fluid loss device
5775428, Nov 20 1996 Baker Hughes Incorporated Whipstock-setting apparatus
5813483, Dec 16 1996 Safety device for use on drilling rigs and process of running large diameter pipe into a well
5960881, Apr 22 1997 Allamon Interests Downhole surge pressure reduction system and method of use
6050340, Mar 27 1998 WEATHERFORD TECHNOLOGY HOLDINGS, LLC Downhole pump installation/removal system and method
6053250, Feb 22 1996 Halliburton Energy Services, Inc. Gravel pack apparatus
6056053, Apr 26 1995 WEATHERFORD TECHNOLOGY HOLDINGS, LLC Cementing systems for wellbores
6079496, Dec 04 1997 Baker Hughes Incorporated Reduced-shock landing collar
6102060, Feb 04 1997 Specialised Petroleum Services Group Limited Detachable locking device for a control valve and method
6155350, May 03 1999 Baker Hughes Incorporated Ball seat with controlled releasing pressure and method setting a downhole tool ball seat with controlled releasing pressure and method setting a downholed tool
6173795, Jun 11 1996 Smith International, Inc Multi-cycle circulating sub
6220350, Dec 01 1998 Halliburton Energy Services, Inc High strength water soluble plug
6227298, Dec 15 1997 Schlumberger Technology Corp. Well isolation system
6253861, Feb 25 1998 Specialised Petroleum Services Group Limited Circulation tool
6293517, Feb 28 2000 John D., McKnight; Brent H., McKnight Ball valve having convex seat
6378609, Mar 30 1999 Halliburton Energy Services, Inc Universal washdown system for gravel packing and fracturing
6474412, May 19 2000 FMC TECHNOLOGIES, INC Tubing hanger landing string with blowout preventer operated release mechanism
6530574, Oct 06 2000 Method and apparatus for expansion sealing concentric tubular structures
6547007, Apr 17 2001 Halliburton Energy Services, Inc PDF valve
6571880, Apr 30 1999 Halliburton Energy Services, Inc Method and multi-purpose apparatus for control of fluid in wellbore casing
6626244, Sep 07 2001 Halliburton Energy Services, Inc Deep-set subsurface safety valve assembly
6634428, May 03 2001 BAKER HUGHES OILFIELD OPERATIONS LLC Delayed opening ball seat
6644412, Apr 25 2001 WEATHERFORD TECHNOLOGY HOLDINGS, LLC Flow control apparatus for use in a wellbore
6666273, May 10 2002 Weatherford Lamb, Inc Valve assembly for use in a wellbore
6668933, Oct 23 2000 ABB Vetco Gray Inc. Ball valve seat and support
6681860, May 18 2001 Dril-Quip, Inc.; Dril-Quip, Inc Downhole tool with port isolation
6712145, Sep 11 2001 FRANK S INTERNATIONAL, LLC Float collar
6712415, Apr 05 2000 DURAKON ACQUISITION CORP Easy to install pull out cargo-carrying tray frame for pickup trucks
6763891, Jul 27 2001 ABB Vetco Gray Inc.; ABB VETCO GRAY INC Production tree with multiple safety barriers
6834726, May 29 2002 Wells Fargo Bank, National Association Method and apparatus to reduce downhole surge pressure using hydrostatic valve
6866100, Aug 23 2002 Wells Fargo Bank, National Association Mechanically opened ball seat and expandable ball seat
6896049, Jul 07 2000 Zeroth Technology Limited Deformable member
6907936, Nov 19 2001 PACKERS PLUS ENERGY SERVICES INC Method and apparatus for wellbore fluid treatment
6948561, Jul 12 2002 Baker Hughes Incorporated Indexing apparatus
6983795, Apr 08 2002 Baker Hughes Incorporated Downhole zone isolation system
7150326, Feb 24 2003 Baker Hughes Incorporated Bi-directional ball seat system and method
7210534, Mar 09 2004 Baker Hughes Incorporated Lock for a downhole tool with a reset feature
7322408, Dec 09 2002 SCHLUMBERGER OILFIELD UK LIMITED Downhole tool with actuable barrier
7322417, Dec 14 2004 Schlumberger Technology Corporation Technique and apparatus for completing multiple zones
7325617, Mar 24 2006 BAKER HUGHES HOLDINGS LLC Frac system without intervention
7337847, Oct 22 2002 Smith International, Inc Multi-cycle downhole apparatus
7350578, Nov 01 2005 ConocoPhillips Company Diverter plugs for use in well bores and associated methods of use
7367399, Oct 06 2003 Halliburton Energy Services, Inc. Loop systems and methods of using the same for conveying and distributing thermal energy into a wellbore
7377321, Dec 14 2004 Schlumberger Technology Corporation Testing, treating, or producing a multi-zone well
7387165, Dec 14 2004 Schlumberger Technology Corporation System for completing multiple well intervals
7416029, Apr 01 2003 SCHLUMBERGER OILFIELD UK LIMITED Downhole tool
7467664, Dec 22 2006 Baker Hughes Incorporated Production actuated mud flow back valve
7503390, Dec 11 2003 Baker Hughes Incorporated Lock mechanism for a sliding sleeve
7503392, Aug 13 2007 BAKER HUGHES HOLDINGS LLC Deformable ball seat
7520336, Jan 16 2007 BAKER HUGHES, A GE COMPANY, LLC Multiple dart drop circulating tool
7730953, Feb 29 2008 Baker Hughes Incorporated Multi-cycle single line switch
7798212, Apr 28 2005 Schlumberger Technology Corporation System and method for forming downhole connections
7832472, Nov 19 2001 Halliburton Energy Services, Inc. Hydraulic open hole packer
7909120, May 03 2005 NOETIC ENGINEERING INC Gripping tool
7971883, Sep 07 2006 HARDINGE, INC Workholding clamping assembly
8061429, Dec 30 2008 Schlumberger Technology Corporation Systems and methods for downhole completions
8291988, Aug 10 2009 BAKER HUGHES HOLDINGS LLC Tubular actuator, system and method
8393389, Apr 20 2007 Halliburton Energy Services, Inc Running tool for expandable liner hanger and associated methods
8443894, Nov 18 2009 Baker Hughes Incorporated Anchor/shifting tool with sequential shift then release functionality
8684096, Apr 02 2009 Schlumberger Technology Corporation Anchor assembly and method of installing anchors
8727010, Apr 27 2009 WELLFIRST TECHNOLOGIES, INC Selective fracturing tool
20010007284,
20020170717,
20040007365,
20040221984,
20050061372,
20050072572,
20050126638,
20050205264,
20060124310,
20060169463,
20060175092,
20060213670,
20060243455,
20070007007,
20070012438,
20070023087,
20070095538,
20070272413,
20070289749,
20080066924,
20080093080,
20080190620,
20080217025,
20080308282,
20090032255,
20090044944,
20090044946,
20090044948,
20090044955,
20090056934,
20090056952,
20090101330,
20090107680,
20090159289,
20090308588,
20100294514,
20110048723,
20110073330,
20110108284,
20110174500,
20110180274,
CA2731161,
CA2760107,
EP427422,
GB2281924,
JP63174808,
WO15943,
/////
Executed onAssignorAssigneeConveyanceFrameReelDoc
May 13 2009XU, YANG Baker Hughes IncorporatedASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS 0274620290 pdf
May 14 2009GERRARD, DAVID P Baker Hughes IncorporatedASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS 0274620290 pdf
Dec 30 2011Baker Hughes Incorporated(assignment on the face of the patent)
Dec 23 2015Baker Hughes IncorporatedBAKER HUGHES OILFIELD OPERATIONS, INC ASSIGNMENT OF ASSIGNORS INTEREST SEE DOCUMENT FOR DETAILS 0373680347 pdf
Jun 01 2017BAKER HUGHES OILFIELD OPERATIONS, INC BAKER HUGHES OILFIELD OPERATIONS LLCCHANGE OF NAME SEE DOCUMENT FOR DETAILS 0430110391 pdf
Date Maintenance Fee Events
Nov 15 2018M1551: Payment of Maintenance Fee, 4th Year, Large Entity.
Oct 20 2022M1552: Payment of Maintenance Fee, 8th Year, Large Entity.


Date Maintenance Schedule
May 26 20184 years fee payment window open
Nov 26 20186 months grace period start (w surcharge)
May 26 2019patent expiry (for year 4)
May 26 20212 years to revive unintentionally abandoned end. (for year 4)
May 26 20228 years fee payment window open
Nov 26 20226 months grace period start (w surcharge)
May 26 2023patent expiry (for year 8)
May 26 20252 years to revive unintentionally abandoned end. (for year 8)
May 26 202612 years fee payment window open
Nov 26 20266 months grace period start (w surcharge)
May 26 2027patent expiry (for year 12)
May 26 20292 years to revive unintentionally abandoned end. (for year 12)